Publicly owned energy company Stanwell is partnering with Tesla and Yurika to build the giant 300MW/1200MWh system capable of supplying energy into the grid for up to four hours.

Related article: Queensland Government doubles capacity of Stanwell battery

The mega battery project will include 324 lithium-ion Tesla Megapack 2XL units which will be transported on trucks to site and craned into place.

The project was recently supercharged with a $448.2 million funding boost from the Queensland Government’s Queensland Renewable Energy and Hydrogen Job Fund, with the Premier and Energy Minister announcing in May it’s capacity would be doubled.

Work has also reached the halfway mark on Stanwell’s first dispatchable energy (storage) project, the $514 million Tarong mega battery project, part of what will be the Tarong Clean Energy Hub.

Stanwell CEO Michael O’Rourke said, “Dispatchable energy assets like our Stanwell and Tarong big battery projects are critical as we transform our energy system.

“The big batteries will play a crucial role in the energy transformation by stabilising energy supply from clean renewable sources, meaning they’ll be able to be charged by sources like wind and solar and pumped back into the grid during periods of high demand.

Related article: CS Energy switches on Chinchilla Battery in Queensland

“This will ensure affordable and reliable electricity for our commercial and industrial customers in Queensland and the Eastern Seaboard.

“They are a key piece of our commitment to achieving 5GW of energy storage by 2035 and highlights Stanwell’s vision for a sustainable and innovative energy future.”

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Commencing commercial operation in 2026, the Brendale BESS is expected to reduce electricity costs and enhance grid stability in line with the Queensland Government’s renewable energy targets.

Related article: Akaysha secures first battery portfolio financing in Australia

Located on UnityWater’s 3.7-acre site next to the South Pine substation, the central node of Queensland’s electricity grid, the Brendale BESS will feature Tesla Megapack technology while the balance of plant will be delivered by Consolidated Power Projects Australia (CPP).

As one of Queensland’s largest batteries, the Brendale BESS can store enough energy to power up to 300,000 homes during a blackout, adding significant storage capacity to Queensland’s electricity network.

The project will provide energy arbitrage and frequency control ancillary services to support the NEM and facilitate the integration of solar and wind projects by leveraging existing transmission infrastructure in the region.

Akaysha Energy managing director and chief commercial officer Paul Curnow said, “The Brendale BESS is an important element of Akaysha Energy’s portfolio across not only Queensland but the NEM more broadly.

Related article: Akaysha Energy: Powering Australia’s renewables transition

“The Brendale BESS is a crucial step in our mission to rapidly deploy large-scale BESS, enhancing grid stability and energy security while driving the global shift to sustainable energy.

“The Brendale BESS is one of four projects under development in the state and it’s clear that the Queensland energy sector is serious about the transition.”

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The $450 million BESS at Lower Wonga has a battery energy storage capacity of up to 200MW and a discharge capacity of up to 800MWh, which is enough power to supply electricity for up to 53,000 homes for four hours.

Related article: Origin approves second stage of Eraring Battery

The Lower Wonga BESS will allow for more solar and wind energy to be integrated into the grid, helping to reduce grid volatility, lower electricity prices and the need for expensive new power stations.

Equis Australia investment director Roby Camagong said, “The BESS would be connected to Queensland’s electricity grid via a transmission line that connects to the 275kV Woolooga Substation.

“Making the transition from fossil fuels to ‘baseload’ renewables, the ability to store and dispatch energy will play a key support role to provide rapid-response services to grid contingency events such as outages or heat waves.

“Grid-scale battery storage fills this key short-term role,” Camagong said.

Work on the battery is expected to begin later this year, with the project scheduled to be operational by 2026.

Related article: FRV Australia reaches financial close on Terang Battery

Equis is developing a pipeline of high-quality battery storage and wind generation projects in Queensland, including the recently announced Jackson North Wind Farm in Woleebee, Queensland.

In November 2023, Equis and the Victorian Government’s SEC financially closed and commenced construction of Phase 1 of the Melbourne Renewable Energy Hub. Once complete, MREH will provide 1.6GWh of energy storage, enough to power up to 200,000 homes during peak periods.

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Related article: Ark gets planning approval for Tasmanian wind farm

The 312MW Wimmera Plains Energy Facility is located 10km north-east from Horsham and includes up to 52 wind turbines connecting to an existing 220kV transmission line.

The project also includes a 100MW Battery Energy Storage system which can store up to 400MWh of dispatchable energy.

The project will reduce greenhouse gas emissions by 1.2 million tonnes of carbon dioxide equivalent per year, which is equivalent to taking more than 370,000 cars off the road each year.

Related article: Queensland Govt approves massive Tarong West Wind Farm

Plans include 52 wind turbines with a blade-tip height of 247m above the ground. Less than one hectare of native vegetation will be disturbed as a result of the project.

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Related article: FRV’s first hybrid solar-plus-storage project goes live

The $1.2 billlion refinancing guarantees the financial support for all the plants as well as a solid backing for future growth and development of new projects. The transaction also secures construction funding for the Terang project, the first utility-scale BESS project of FRV Australia, with a capacity of 100MW capacity in Victoria.

The transaction includes all FRV Australia’s operating and under-construction plants, including Lilyvale, Moree, Sebastopol, Goonumbla, Metz, Winton, Walla Walla and Dalby.

FRV Australia CEO Carlo Frigerio said, “We are thrilled to achieve this significant milestone in our journey This refinancing not only secures the future of our current operations but also provides a strong foundation for our continued growth and commitment to developing renewable energy projects across Australia.”

Related article: FRV reaches financial close on Walla Walla Solar Farm

The refinancing process involved eleven financial institutions, including ING Bank, Westpac Banking Corporation, MUFG Bank, Société Générale, Norddeutsche Landesbank, Mizuho Bank, Intesa Sanpaolo, United Overseas Bank, the Clean Energy Finance Corporation, China Construction Bank and Agricultural Bank of China.

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The continual political manoeuvring and propaganda associated with renewable energy sources and associated energy costs render little light, generate a lot of heat and take the national gaze off the truly urgent matter of securing the stability and proper functioning of the national electricity grid.

These notes regarding the transition to renewable energy sources in the NEM are not tinged with propaganda; rather they express a well-founded concern for the viability of the national electricity system, which is heightened by political agendas. The recent Australian Energy Week Convention in Melbourne in June provided sufficient grounds to question the development of the transition.

Related article: Barking up the wrong tree—an engineer’s perspective

The worrying elements in addition to climate considerations are twofold; economic and technical. The concentration here is on technical aspects, and this focus is based on the belief that technical viability of the grid underpins the proper functioning of the entire Australian economy. The economies associated with various forms of electricity generation, be it wind, solar, gas, hydrogen, hydro or nuclear, are not addressed here.

It is not because discussion on the relative energy costs is not important to owners and consumers. Rather, it is that a national grid subject to instability, islanding and blackout has a far more negative effect on the entire Australian economy then the individual profit motives of market participants.

The continual political manoeuvring and propaganda associated with renewable energy sources and associated energy costs render little light, generate a lot of heat and take the national gaze off the truly urgent matter of securing the stability and proper functioning of the national electricity grid.

A speaker at the AEW Convention cut to the chase by stating that the National Electricity Law is no longer fit for purpose, and that the independently formulated renewable energy zones and transmission links by various jurisdictions are counterproductive to the integration process.

In the following discussion, the elements of constituting the technical viability of a large renewable grid are unpicked.

1. The NEM is, other than for two DC links, an alternating current (AC) system of interconnected generators and energy consumption (load) centres.
2. The various states are interconnected and an important question that must be answered is if nationally it is considered important that each state be energy-wise, self-sufficient. Note: the question is basically a design condition, i.e., is this a must or not.
3. The basis of an AC system is stability of voltage, frequency and synchronicity. These must be maintained in a contiguous grid. Inter alia: a design condition can be that instability, resulting in the grid becoming a number of island grids, can be tolerated because each island can safely continue operating.
4. Voltage stability is a result of having strong networks. Note: the concept of grid strength is explained further down. Frequency stability results from two important factors; (a) stable or slowly varying electrical loads, (b) having sufficient inertia, (c) having sufficient generator capacity available at all times (note: capacity is expressed in MVA or GVA).

Let’s turn our attention to renewable sources, specifically wind and solar. Where these make up the bulk of all energy we encounter weak grid strength, unless we remediate this, for example by utilising synchronous condensers. Note: our attention here is on high-voltage, transmission grid-connected solar and wind generators.

A weak grid is one in which voltage varies significantly with electrical power being generated. Weak grids not only suffer voltage variability, but the connected solar and wind generators face difficulty in remaining synchronised.

Note: the bulk of these generators are of the grid-following type. Voltage variability tends to ‘confuse’ their voltage tracking ability (achieved through circuitry—the phase locked loop) that can only be ‘tuned’ to a small extent. As explained below, the criterion for connection is that there be sufficient grid strength at the point of connection (PoC) of the generator in question by measurement of the short circuit ratio (SCR) at the PoC.

We will examine two examples to clarify the grid strength issue. (i) a coal or gas-fired synchronous generator providing some, but not all of the energy needs of a zone substation, i.e. an energy consumption centre, a large distance from the synchronous generator. A solar farm near the zone substation is connected to the end of the transmission line and would meet the energy shortfall of the zone substation.
(ii) The case of the synchronous generator being replaced by a battery energy supply system (BESS) and grid forming inverter.

To determine grid strength, in order to gain approval from AEMO to connect the solar farm to the grid at the PoC near the zone substation, the SCR at the PoC must be established. This requires a calculation: first, the transmission line is assumed short-circuited at the PoC (the solar farm is assumed not be connected) and the output of the generator at the other end of the transmission line—i.e., (i) the synchronous generator and the (ii), the BESS-grid forming inverter) short circuit power capacity, usually measured in MVA, is determined.

In the case of (i), the synchronous generator, the short circuit MVA is four times higher than its rated power output. For the sake of a numerical example, assume the rated power to be 150MVA. Its short circuit power is therefore 4 x 150MVA, i.e., 600MVA if the short circuit takes place at the generator. However, at the far end, i.e., at the PoC, a short circuit there reduces the synchronous generator short circuit power because it faces a long transmission. Let us assume the reduction is 50%. Therefore, at the PoC, the short circuit amount 600MVA divided by 2, equals 300MVA.

In the case of (ii), the BESS-grid forming inverter, it is also rated at 150MVA. However, its short circuit capacity is 1.3 times its rated power, i.e., 195MVA. At the PoC, this is reduced by 50% as well, i.e., approx., 85MVA.

Assume that AEMO specifies that the SCR, that is the ratio of the short circuit capacity at the PoC divided by the proposed solar farm rated power, must be three or higher. In the case of (i), the synchronous generator case, the solar farm can have a maximum power of 300MVA divided by 3, equals 100MVA, whereas for (ii), the BESS-grid forming inverter, it is 85 divided by 3, equals 28MVA.

What would happen if a second solar farm also wants to connect? According to the above, it would be limited to 28MVA, adding to the already existing generation capacity, and thus making the SCR for the BESS-grid forming inverter case equal 85 (its short circuit capacity at the PoC) divided by 56, i.e., 1.5, and therefore too low. Both plant owners may now be called on to install a synchronous condenser, to boost short circuit capacity at the PoC.

It is now clear as solar and wind generators replace synchronous generation that grid strength declines, therefore requiring augmentation by synchronous condensers or measures such as var compensators, static synchronous compensators, or thyristor-controlled series capacitors. Decline in grid strength will require major augmentation capital expenditure.

Finally, we look at inertia. More inertia means more energy stored in rotating masses, i.e., the rotor-turbines of synchronous generators and synchronous condensers plus flywheels, and all direct-on line AC motors. The rotating (kinetic) energy can provide sufficient time for generator controls to restore frequency when imbalances between demanded and generated power occur. Changes in climatic conditions can make the changes sharper when we have a lot of wind and solar generation, as well as loads such as air conditioners.

Statically stored energy, for example in batteries, is subtly different: it can, through the employment of inverters perform the same task of rotating, kinetic energy. However, whereas spinning rotors directly provide frequency, this is not case for inverters. The latter rely on control functions, generally commercial-in confidence, to respond frequency-wise.

This lack of uniformity, in contrast to that provided by the immutable laws of physics governing synchronous generators and other electro-dynamic loads, provides a great challenge in the protection engineering regime of renewable grids. We are thus facing a large knowledge gap, to wit:

1. Finding economical solutions to increase grid strength
2. Creation of sufficient uniformity in grid following and grid forming inverters, in order to have predictability of delta power-delta frequency and delta-time response
3. Reparameterisation of protection relays including power oscillation blocking and out-of-step relays, also in regard to planned retention levels of synchronous generator MVA capacity.
4. Configuring dynamic restraint of under-frequency, load-shedding relays to take account of increased rates of change of frequency and frequency nadirs.

Related article: Fibs about the renewables transition—and the cost of energy

In conclusion, we are not an impossible transition-to-renewables journey; rather we are on one with no effective overall system engineering direction and supervision. We are thus given a choice between slowing the transition or facing increasing grid failures, or retaining synchronous capacity in one form or another.

It would be best if this were recognised by state and federal governments, as well as their loyal oppositions, and in doing so abdicating their authority to a national, central Australian grid engineering company with the appropriate planning and coordination charter.

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The combined energy storage of the stage one and stage two batteries will be over 2GWh, enabling Origin to help keep the grid stable and support more variable renewable energy coming into the system.

Related article: Origin strikes deal with govt to delay Eraring closure

Origin has executed agreements for equipment supply and construction, with works on the second stage scheduled to begin early in the 2025 calendar year. Stage two is anticipated to come online in the first quarter of the 2027 calendar year.

Origin head of energy supply and operations Greg Jarvis said, “We are pleased to have approved Origin’s third investment in a large-scale battery at one of our existing power stations, which reflects our belief that storage will play an important role in the changing grid by helping to firm up variable supply from wind and solar.

“The second stage of the Eraring battery will be over four-hours duration and it will be capable of absorbing excess solar generation during the day to support reliable energy supply when needed, such as through the evening peak.

“Eraring is a strategic site with high-quality connection infrastructure. Confirmation of the second stage of the Eraring battery development is a key next step as we look to transform the site for the future so it can continue to support the energy transition.”

Battery equipment for stage two of the Eraring project will be supplied by Finnish technology group Wärtsilä, with design and construction services to be provided by Enerven Energy Infrastructure.

Related article: Supernode Battery expanded under new Origin offtake deal

Origin has now committed to more than 1.5GW of large-scale batteries across its three owned projects at Eraring and Mortlake, along with tolling agreements for the offtake of the Supernode Battery stage 1 and 2.

Eraring is Australia’s largest power station and supplies up to a quarter of electricity supply in New South Wales. Eraring is scheduled to close in August 2027, as part of an agreement with the NSW Government to support security of supply through the transition.

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Related article: Edify and Sosteneo partner to build Koorangie ESS

The Tesla Megapacks have arrived and been successfully craned into place at the KESS site, with the Hon. Lily D’Ambrosio MP onsite to help celebrate the milestone.

The Koorangie Energy Storage System is located in North West Victoria, near the town of Kerang.

Construction of the 185MW/370MWh KESS facility is on schedule and charging towards energisation and commercial operations in 2025.

KESS will be able to power 350,000 homes for 2 hours. With its grid forming capabilities, it will liberate significant renewable energy capacity in the region supporting Victoria’s and Australia’s renewable energy transition.

KESS has entered into a 15-year offtake agreement with Shell Energy and in parallel provides critical system strength services through a 20 year System Support Agreement with AEMO.

To finance and deliver the $400 million Koorangie Energy Storage System, one of the largest and most advanced energy storage systems on the network, Edify has partnered with Sosteneo, a specialist infrastructure investor.

Related article: Edify gets $48M funding for Townsville Green Hydrogen Hub

Minister D’Ambrosio said, “Koorangie is a cutting-edge facility that will help Victoria hit our energy storage targets and support our transition to renewable energy that will provide stability to our energy grid regional Victoria.”

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Related article: Pacific Green to build grid-scale battery park in Victoria

The Limestone Coast Energy Park assets will consist of a 0.5GW/1.5GWh battery energy storage system developed and constructed in two phases over the next 36 months. Once operational they will significantly strengthen the region’s grid stability.

Construction of the energy parks will commence towards the end of this year, with the first phase expected to be operational in the second half of 2026.

The Limestone Coast Energy Parks mark the first set of assets of an 8.5GWh development pipeline of battery energy parks Pacific Green is rolling out throughout Australia.

Pacific Green Australia CEO and managing director Joel Alexander said, “This is a major milestone for the Limestone Coast Energy Park assets, and we are pleased that the South Australian Government has recognised the rigorous assessment and community consultation work we have undertaken to date.

“We look forward to re-engaging with the local community to maximise the tangible economic benefits of the Limestone Coast Energy Parks and to ensure funding and local contracting opportunities are open to all relevant groups.

Related article: Octopus’ 1GWh Blackstone Battery gets planning tick

“This is a positive and exciting start to an exceptional pipeline of Australian projects to come.”

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The lender group is made up of domestic banks including ANZ, CBA and Westpac, and international banks BNP, Canadian Imperial Bank of Commerce, DBS, ING, Mizuho, Rabobank, Siemens Financial Services through Siemens Bank, and SMBC.

The facility has a tenor of three years and will be used to fund the construction of Akaysha’s latest project, Orana, which is located near Wellington, NSW within the Central West Orana Renewable Energy Zone (REZ).

Related article: Akaysha secures first battery portfolio financing in Australia

Akaysha managing director and chief financial officer Andrew Wegman said, “We are very pleased to announce the successful closing of the debt financing of the Orana project as we move into construction on Akaysha’s first four-hour BESS to date.

“As the largest standalone BESS financing globally, this achievement not only secures the capital for Orana’s construction but also highlights the strong support we have received from both local and international banks, as well as from BlackRock. Their commitment to advancing the energy transition in Australia and internationally has been pivotal to reaching this milestone.

“This milestone is a significant accomplishment for Akaysha and an important step for Australia’s energy transition.”

Central to the debt financing is an innovative 12-year ‘virtual toll’ offtake agreement secured with leading generator and retailer, EnergyAustralia for 200MW of contracted capacity.

This is the first of its kind for EnergyAustralia and, as a financial product, will allow it to notionally charge and discharge 200MW of a virtual battery within pre-agreed daily bidding parameters, separate from the physical operation of the battery by Akaysha.

Related article: Akaysha inks battery storage deal with Japan’s Itochu Corp

EnergyAustralia says the offtake agreement aligns strategically with the Australian customer in mind and ensures the delivery of its energy is both secure and reliable.

Akaysha’s Orana BESS is being developed within the Central West Orana Renewable Energy Zone, adjacent to the Transgrid substation near Wellington, NSW.

Early works have begun on the project, which will feature Tesla Megapack technology and balance of plant will be delivered by Consolidated Power Projects Australia (CPP). The Orana BESS is expected to commence commercial operations in 2026.

The post Akaysha secures largest BESS financing globally at $650M appeared first on Energy Source & Distribution.

The expansion features a 250MW/4hr Battery Energy Storage System (BESS), which is double the megawatt-hour size of the Stage 1 BESS project recently announced.

Related article: Quinbrook to build $2.5b data centre with 2GWh battery

Quinbrook Infrastructure Partners co-founder and managing partner David Scaysbrook said, “Supernode Stage 2 expansion comes right on the heels of our recent announcement of the construction start for Stage 1 and of our long-term offtake partnership with Origin.

“Moreover, with a 4-hour duration now configured for Stage 2, this represents yet another significant milestone for Quinbrook and for Queensland’s energy transition. Origin’s commitment to both Stages 1 and 2 speaks volumes to how strategically located the Supernode site is within the Queensland power system.

“The South Pine switchyard is the central node of the electricity network in Queensland, with an estimated 80% of Queensland’s traded electricity flowing through here every day. It’s hard to imagine a more ideal location for storage in the sunshine state.”

The Supernode site is the last non-flood prone land adjacent to the South Pine central node.​ This proximity helps mitigate marginal loss factor and curtailment risk, offering competitive advantages for Supernode BESS operations.

Related article: Octopus’ 1GWh Blackstone Battery gets planning tick

Origin head of energy supply and operations Greg Jarvis said, “Origin is pleased to be working with Quinbrook having secured the exclusive offtake from Stage 1 and 2 of the Supernode battery.

“The Supernode offtake will be an important addition to our growing storage portfolio, and reflects our belief that storage will play an important role in helping firm variable renewable energy supply and maintaining secure, reliable energy supply for customers.”

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The Territory Government’s Power and Water Corporation has secured conditional support from the Australian Renewable Energy Agency (ARENA) for 16 community batteries, which will be located in various locations on the Darwin-Katherine electricity grid.

Related article: Northern Territory claims highest take-up of solar batteries

Once online, the batteries are expected to have a significant impact on local network constraints and will expand rooftop solar capacity, reduce emissions and keep power prices as affordable as possible.

The $6.1 million Wurrumiyanga Solar Farm project is also a step closer to having battery storage. Testing of the battery which was undertaken at Berrimah is now complete.

This project will provide an additional 1.1MW solar array, together with a 1.75MVA battery energy storage system. The battery has been prepared for transport to Wurrumiyanga, where work will begin to connect the battery to the solar farm in the coming months.

Work on the Remote Power System Strategy, which will deliver an average of 70% renewable energy to 72 remote communities provided with electricity through the Indigenous Essential Services program is continuing.

The Northern Territory Government invested $3.1 million for preparatory works for the rollout of more solar and batteries in remote communities, including detailed technical analysis. The RPSS will reduce the reliance of diesel generators in regional and remote communities.

Minister for Renewables and Energy Kate Worden said, “Investing in battery technology ensures Territorians will have reliable power supply as we move to integrate more renewable energy into our electricity grid.

Related article: Northern Territory to upgrade substation at Berrimah

“We can make these investments because the Territory Government owns our assets like Power and Water, Territory Generation and Jacana.

“Because we own our assets, we can keep the cost of power low. We also subside the power bill of every Territory household by $1,500 a year through the Community Service Obligation.”

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Related article: Green Wind reveals plan for 600MW wind farm in WA

Cannie Wind Farm is awaiting referral decision on whether it requires environmental assessment under the Environment Protection and Biodiversity Conservation Act 1999 (EPBC Act).

The proposed project will be located approximately 25km northwest of Kerang, in the Gannawarra Shire Council area.

RES has updated preliminary constraints mapping of the site and as a result has reduced the number of wind turbines to a maximum of 174 (from the previously advised maximum of 200 turbines). Wind turbines will have a blade tip height of up to 280m.

The proposed site extends over 17,000 hectares of land predominately used for grazing and cropping. Landowners within the wind farm boundary have entered into preliminary agreements with RES to host the wind farm.

Related article: Windlab’s Gawara Baya Wind Farm gets green light

Cannie Wind Farm is expected to generate enough electricity to supply over 600,000 Victorian homes.

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Related article: INPEX to build solar and battery project in New South Wales

Pacific Partnerships will develop invest in, and manage delivery and operations of the Cobbora Solar Farm and BESS, located across a 3,000ha site near Dubbo.

Fellow CIMIC company UGL will undertake early works, develop the project solution, and provide operation and maintenance services once completed.

The project will be built on mostly cleared grazing land. It is being designed with minimal long-term disruption to the land, and current productive sheep grazing is expected to continue when the solar farm is operational.

Pacific Partnerships purchased the project from Marble Energy, a renewable energy developer based in Sydney.

Related article: Farmers score affordable solar thanks to new partnership

Marble Energy co-director Tim Kirk said, “The Cobbora Solar Farm will be located on a low, undulating landscape. This makes it an ideal site for a solar farm development. We look forward to continuing to support the project through the development process.”

Cobbora Solar Farm will connect to the national network via infrastructure to be delivered by EnergyCo NSW as part of the CWO REZ.

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